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2013 HALF-YEARLY RESULTSTullow Oil plc31 July 2013

2013 HALF-YEARLY RESULTSDisclaimerThis presentation contains certain forward-looking statements that are subject to the usual risk factorsand uncertainties associated with the oil and gas exploration and production business.Whilst Tullow believes the expectations reflected herein to be reasonable in light of the informationavailable to them at this time, the actual outcome may be materially different owing to factors beyondthe Group’s control or within the Group’s control where, for example, the Group decides on a change ofplan or strategy.The Group undertakes no obligation to revise any such forward-looking statements to reflect anychanges in the Group’s expectations or any change in circumstances, events or the Group’s plans andstrategy. Accordingly no reliance may be placed on the figures contained in such forward lookingstatements.Slide 2

2013 HALF-YEARLY RESULTSRunning business for the long-term• Financial strength and funding of thebusiness has never been stronger• Core oil producing assets continue togenerate significant cash flow• Successfully adding commercialreserves and contingent resources• Selectively developing / monetisingkey projects• East African Rift Basins position willsignificantly enhance valueContinued track record of opening high-risk frontier basinsSlide 5

2013 HALF-YEARLY RESULTSTullow Oil plc – 2013 Half-yearly resultsFinance – Ian Springett

2013 HALF-YEARLY RESULTS2013 half-yearly results summary1H 2013 1H 2012 ChangeSales revenue $1,347m $1,167m +15%Gross profit $764m $679m +13%Administrative ExpensesProfit on disposalExploration costs written off($89m)-($176m)($95m)$702m($451m)Operating profit $500m $834m -40%Profit after tax $313m $567m -45%Basic earnings per share 32.2c 60.3c -47%Dividend per share 4.0p 4.0p 0%Capital investment 1 $804m $926m -13%Cash generated from operations 2 $1,016m $875m +16%Net debt 3 $1,729m $695m +149%12013 excludes Spring acquisition2Before working capital movements3Net debt is cash and cash equivalents less financial liabilitiesIncreased Jubilee production generates higher revenues and cash flows.Excluding 1H 2012 disposal proceeds, profits also improvedSlide 7

2013 HALF-YEARLY RESULTSNet income 1H 2013 v 1H 2012$m1,000750722751991170250023250567089 93130Net Income1H 2012Price Volume OperatingcostsOther costs ExplorationWrite-offsGain ondisposalNet Finance Tax IAS 39 Net Income1H 2013Gross profit up 13%; increased volumes produced partially offset by higher operating costs andDD&A. Reported Net income however is lower due to the one-off gain on Uganda farm down in2012 partially offset by lower exploration costs in 2013.Slide 8

2013 HALF-YEARLY RESULTSSources and uses of fundsCash inflow $1,961m• Operating cash flow $1,057m * (1H 2012:$862m * )• Disposals nil (1H 2012:$2,568m)• Net loan draw down $901m(1H 2012 repayment :$2,050m)• Share proceeds $3m (1H 2012:$15m)$m2,0001,5001H 2013 Net cash inflow $227mSourcesUses$3m$177m$901m$291mCash outflow $1,734m• Cash Capex $847m (1H 2012:Capex $898m)1,000$419m• Acquisition costs $419 million (1H 2012 nil)• Cash tax paid $291m (1H 2012:$204m)• Finance Costs & fees, & Dividends $177m(1H 2012:$165m)500$1,057m$847mNet cash inflow $227m• Increase in cash balances* After working capital0Cash InflowShare proceedsNet loan draw downOperating Cash flowCash OutflowFinance costs and dividendsTaxAcquisitionsCapexSlide 9

2013 HALF-YEARLY RESULTS2013 capital expenditure$2.0 billion capex for full year 20132013$900m$250m$850m$2,000m• Ghana: Jubilee Phase 1A & TEN developments• Uganda: Appraisal activities• Kenya: Exploration drilling2012$756m$338m$776m$1,870m• Other Africa: Maintaining mature production& high impact exploration• ROW: French Guiana appraisal and selected highimpact exploration2011$445m$591m$396m$1,432m1H 2013 capital split:• 25% Ghana; 70% Africa2010$382m $138m $715m$1,235m0 500 1000 1500 2000 2500Expl App Dev$208mSouth & EastAfrica1H 2013$804m$241mEurope,S. America& AsiaNotes:i) 2013 Capital Expenditure excludes the Spring acquisition expenditureii) 2013 Exploration expenditure is net of Norwegian tax refundiii) 2011 Capital Expenditure excludes the Nuon and Ghana EO acquisition expenditure .iv) 2010 Capital Expenditure excludes the Heritage licence and Ghana FPSO lease acquisition expenditure$355mWest &North AfricaSlide 10

2013 HALF-YEARLY RESULTSTullow’s exploration-led value growth strategyAdditional cash flow from new productionHigh MarginProductionCash flowExploration andAppraisal$1bn + p.a.Fully FundedMonetisationOptions &PortfolioManagement~$4bn debt facilitiesSelectiveDevelopmentCosts &DividendsSurplus CashAdditionalExploration, CashDistributionExploration and AppraisalMonetisationSelective DevelopmentSignificant success in Kenya; resource estimates doubled at Ngamia and Twiga S followingsuccessful flow testing; further discovery at EtukoGood progress TEN farmdown – advisors appointed, Government discussions on carry structure,early marketing commenced, data room Aug/Sept.Bangladesh sale being finalised; Initial bids received N Sea assetsTEN project proceeding to final contract awards; MOU being finalised in Uganda for basincommercialisation plan; already looking at development options for KenyaSlide 11

2013 HALF-YEARLY RESULTSStrong Balance Sheet• Improved 2013 revenues, operating cash flow and income (exc. 1H12 disposal profits)• Strong, well funded balance sheet- Debt facilities $4 billion; net debt $1.7 billion; un-utilised debt capacity $1.7 billion- Increasing operational cash flow and portfolio activity• Significant value growth opportunities- Significant progress in Kenya, Ethiopia & Uganda- Executing major development project in Ghana- High impact new campaigns; Mauritania, Guinea, Norway• Funding strategy for next phase of growth- Strong production cashflow, plus continued portfolio high grading/monetisation- Selectively develop key projects, but significantly reduce capex exposure- Further debt diversification; continued hedge protectionSlide 12

2013 HALF-YEARLY RESULTSTullow Oil plc – 2013 Half-yearly resultsDevelopment and Operations – Paul McDade

kboepdkboepdkboepd2013 HALF-YEARLY RESULTSHigh quality African focused oil production1009080706050403020100Group Working Interest Production2012 actual 1H 2013actual2013guidance2014estimateEuropeAsiaGhanaRest of AfricaGhana – Jubilee operatedproduction40353025201510502012 1H 2013 2013 2014Current productionFuture productionOther licence areas2013 Guidance: 84 – 88,000 boepdNon-operated WestAfrica Production• 1H 2013 production at 88,600 boepd40• Jubilee currently producing around 110kbopd gross• 2H 2013 production reduced due to plantmaintenanceImproving quality of production portfolio3530252015105MauritaniaCongo (Brazz)Cote d'IvoireEq GuineaGabon• Working on Jubilee FPSO capacity• TEN will contribute in 201602012 1H 2013 2013 2014• East Africa moving towards production• Active management of development portfolio• Asia and SNS sale process ongoingStable high value production portfolioto fund future exploration programmesSlide 14

2013 HALF-YEARLY RESULTSWest Africa – high quality non-operated portfolio of assetsGabon• Portfolio of 10 fields with net production >13,000 bopd• Continuous campaign of development and appraisal activity• Currently ongoing well activities across 5 fieldsEquatorial Guinea• Ceiba stable at ~4,000 bopd following successful infill campaign• Okume 3Q infill drilling campaign to maintain production >6,000 bopd• 4D seismic continues to identify future infill targetsCôte d’Ivoire• Espoir production ~3,500 bopd• Infill drilling campaign planned to commence in Q2 2014Mauritania & Congo• Combined production remains stable at ~4,000 bopd• Banda gas project, commercial & technical activities progressingMauritania / Congo18%1H 2013 Dev CapexCôte d’Ivoire10% $122mEG35%Mauritania / Congo10%Côte d’Ivoire8%EG33%1H 2013 Revenue$513mGabon37%Gabon49%Slide 15

2013 HALF-YEARLY RESULTSJubilee field on track to exit year at over 120,000 bopdCurrent production stable• Existing wells stable and productivity stable post acid jobs• Initial Phase 1A wells onstream and performing to target• Well capacity now ~130,000 bopd• Production stable at ~110,000 bopd, constrained by gasFPSO capacity being optimised over Q3• Gas compression upgrade on track• Additional gas injection well being drilled• Water injection pump replacement required• First full shutdown scheduled for September• Remaining Phase 1A wells will be completed as needed• Target remains to exit year > 120,000 bopdFuture expansion potential being worked• Full Field Development Plan being discussed with Government• Options to increase FPSO capacity under review toaccelerate production and provide tie-back optionsSlide 16

2013 HALF-YEARLY RESULTSTEN development – approval received and project underwayRecent well results encouraging• Enyenra-6A confirms deeper OWC• Nt-04 confirms OWC and supports water injection plans• Base case reserves of initial development ~300mmboePoD approved; contract awards in progress• Base plan of 24 wells• FPSO capacity of 80,000 bopd• Major FPSO and Subsea contract awards in progress• First oil by mid-year 2016• Gross development capex of ~$4.9bn + leased FPSOTullow capex exposure being managed• Tullow net capex to first oil ~$1.5bn (10 wells)• Farmdown process initiatedmmboe P90 P50 P10TEN Reserves & Resources * 200 360 600Oil/Gas Ratio (%) 80:20 70:30 60:40* Excludes prospective resourcesSlide 17

2013 HALF-YEARLY RESULTSEarly South Lokichar Basin successSignificant early drilling success• 100% exploration success from first 3 wells in Blocks 13T/10BB• Successful testing of Ngamia-1 and Twiga South-1- Net oil pay estimates doubled- Cumulative flow potential of over 5,000 bopd per well• Successful application for Area of Interest (AOI)- Allows co-ordination of appraisal and exploration activities• Discovered resources well in excess of 300 mmboPlanned appraisal activities• Multiple appraisal wells planned through to end of 2014• 550sq km 3D seismic programme commencing in Q3 2013• Extended well testing to assist in proving of volumes andcharacterisation of reservoir quality and connectivityBasin development options under review• “Start up” production of up to 10,000 bopd- Review underway of crude export by road and/or rail• Early stage work for pipeline export underway in preparationfor commerciality being declaredSimilar basin volume potential as Uganda’s Lake AlbertSlide 18

2013 HALF-YEARLY RESULTSMoving closer to regional export pipelineUgandan appraisal underpins resources• Successful appraisal activity supports discoveredresources of 1.7bn• Further seismic, drilling and testing ongoing• Development studies progressing• MOU principles agreed, final details being progressedRegional pipeline• Ugandan & Kenyan Presidents agree joint export pipeline• Kenya nominated to lead pipeline project• Northern route provides greatest regional synergies• Concept work on pipeline and offshore loading complete• Pre-FEED activities expected to start imminentlySlide 19

2013 HALF-YEARLY RESULTSHigh quality portfolio of production and developments• Strong production delivery from West African production portfolio• TEN first oil in mid-2016 whilst managing exposure to development capex• Kenya/Uganda progressing towards integrated pipeline development• Significant focus on managed commercialisation of Kenya/Uganda resources• Asia and SNS sale process ongoing for 2013 disposalSlide 20

2013 HALF-YEARLY RESULTSTullow Oil plc – 2013 Half-Yearly ResultsExploration & Appraisal – Angus McCoss

2013 HALF-YEARLY RESULTSOil exploration strategy focused on Africa & Atlantic MarginsNorth AtlanticExploration Campaign &Business DevelopmentNorwegianContinental ShelfCentral AtlanticMajor ExplorationCampaign LaunchedCentral AtlanticMarginEast AfricanRift BasinsGuyanasTransform MarginEast AfricanTransform MarginEquatorial AtlanticExploration Campaignongoing since 2007Core PlaysStrat TrapsSalt BasinsSouth AtlanticExploration Studies &Business DevelopmentWest AfricanTransform MarginRift BasinsCarbonatesSlide 22

Tullow Net MMboeIRR2013 HALF-YEARLY RESULTSExploration delivers volumes & value700600Jobi East-1,Gunya-AJobi-3/4/530%25%Low volume,high valueLeadingIndependentsHigh volume,high value500Nigiri-220%40015%300Jobi-1, Rii-1Enyenra-2A, 3AZaedyus-12001000Kenya2013Mahogany-1,Hyedua-1Mahogany-2 & 3Tweneboa-1, 2Owo-1East AfricaAtlantic Margins2007 2008 2009 2010 2011 201210%5%MajorsLow volume,low valueGas giantsHigh volume,low value0%10% 100% 1000%New volumes/production200 Mmboe average annual resource additions Highly competitive returns from explorationUganda at original equities, no uplift from Heritage acquisitionSource: Wood Mackenzie Exploration Service Corporate Benchmarking Report, October 2012.Slide 23

2013 HALF-YEARLY RESULTSExploration campaigns compete & evolve to grow value2005 Adapting to outcomes & reproducing successes2015+East African Rift BasinsEast African MarginUgandaTanzaniaKenyaEthiopiaMozambiqueMadagascarEast Africa• Uganda: prolific oil basin opened• Uganda: $2.9B dilution proceeds• Kenya & Ethiopia: multiple rift basinswith similar potential• South Lokichar Basin so far found over300mmbo, 3/3 wells• Achieved threshold volume fordevelopment in only 16 months• Wildcats target more rift basinsEquatorial & Central AtlanticEquatorial GuineaNorth AtlanticUKMauritaniaGhana SL/LibGuineaGuyanas / SurinameNetherlandsGreenlandNorwayAtlantic Margins• Ghana: prolific oil basin opened• Jubilee core revenue generator• TEN commercialisation ongoing• Spread of 3 campaigns to find “nextJubilee” revenue stream• Campaigns high-graded & refocusedafter each well result• Switch from Southern North Sea gas toNorth Atlantic oil• Spring Energy acquiredSchematic scalesSlide 24

2013 HALF-YEARLY RESULTSIndustry-leading exploration acreage positionBalanced spread of E&A campaigns provide robust feedstock to sustain Tullow’saverage annual addition of 200MMboe mean resourcesSlide 25

2013 HALF-YEARLY RESULTSIndustry-leading exploration acreage positionSouth American Atlantic Margins• 1 out of 4 French Guiana wells successful, next well to delineate Zaedyus water leg• Mid-term focus turns to Suriname operated venture & to remaining French Guiana prospectivityCentral Atlantic Margins• Frégate-1 to spud in August on Cretaceous turbidite prospect “Scorpion”• Following wildcats will target Tapendar, Sidewinder & IbisWest African Atlantic Margins• Focus shifts to Paon-2 exploratory appraisal in Côte d’Ivoire & to Guinea prospects Sylli & Eos• Sierra Leone & Liberia positions under reviewEast African Rift Basins• 3 out of 3 successes in South Lokichar Basin – near commercial threshold• Preparing for basin opening wildcats in the Omo, Chew Bahir, Kerio & North Lokichar BasinsEast African Transform Margin• Cachalote discovery offshore Mozambique being followed up at Buzio-1• Offshore commercialisation options under studyNorth Atlantic Margins• Key wells: Mantra, adjacent to Troll; Wisting in Barents Sea and high-risk play-tester at Kuro• Billion barrel prospect mapped in Greenland acreage & reviewing options to realise valueSlide 26

Gross Potential in Billion Barrels2013 HALF-YEARLY RESULTSCampaign of 12 East African Tertiary Rift BasinsCampaign concept proved in Lake Albert Rift Basin, UgandaTullow Oil’s 12 East African Tertiary Rift BasinsMputa-1BasinopenerKasamene-1PlayopenersWaraga-1Follow-on ProspectFollow-on ProspectFollow-on ProspectFollow-on ProspectFollow-on ProspectFollow-on ProspectFollow-on Prospect1.7BboUgandaEthiopiaLake Albert Chew Bahir Omo West OmoKenya2014Kingfisher-1Follow-on ProspectFollow-on ProspectTurkana Turkwel North Lokichar South Lokichar2014121086Possible campaign scenarios8/12 basinssuccessful4/12 basinssuccessful2014Kerio Suguta Kerio Valley Nyanza420Years2/12 basinssuccessful1/12 basinsMultiplying our success based on Lake Albert Rift Basinthrough an integrated E&A campaign across12 East African Rift BasinsAchieved immediate success in South Lokichar BasinSlide 27

2013 HALF-YEARLY RESULTSTechnology steps up from FTG to AEI (Ambient Enhanced Inversion)Active methodsAmbient enhancementWell Logs Seismic Surveys Electro-MagneticLaboratory Borehole Seismic Earthquakes GravityHighSensitivityLowSensitivityHigh ResolutionLocal MeasurementLow ResolutionRegional MeasurementPioneering application of Full Spectrum Geophysics by Tullow to find oil in the Tertiary Rift Basins of East Africa• Tullow integrates free & natural ambient energy to enhance standard active geophysical methods• Appling overlapping geophysical methods to invert geophysical data into geology models to help locate oilSlide 28

2013 HALF-YEARLY RESULTSKenya – Ethiopia: World class petroleum province potentialThree scales of exploration in multiple basins1. Ngamia-1 & Twiga South-1 appraisal testingdoubles pay (25 sq km)• 10kbopd total combined flow rate potential fromthese 2 wells2. South Lokichar Basin drill-out : already exceedsthreshold for development (10,000 sq km)• >300 mmbo confirmed in 3 wells• Multiple oil plays proved as Etuko-1 makes importantnew oil discovery3. High-grading multiple basins through wildcatdrilling (100,000 sq km)• Sabisa-1 establishes Omo Basin is oil proneSlide 29

2013 HALF-YEARLY RESULTSKenya: South Lokichar Basin exceeds threshold for developmentNgamia-1200m net pay(near crest)5kbopd potentialTwiga S-175m net pay(down flank)5kbopd potentialEtuko-1>40m net payEkales (Drilling)Agete NorthAgete SouthEtomAmosingEkosowanEwoiEkunyukKapeliKedikediKoriMeriNgorokRift BoundingFault Play:“String of pearls”like Kingfisher inLake AlbertRift Flank Play:“Prospect Cascades”like Kasamene inLake Albert• Ngamia-1, Twiga S-1 & Etuko-1 prove prolific light oil basin with at least Lake Albert Rift Basin resource potential• 2 rigs drilling out the Rift Bounding Fault Play & Rift Flank Play• 3 rd rig & dedicated testing unit contracted to support increased E&A activity in Kenya by year-endSlide 30

2013 HALF-YEARLY RESULTSKenya: Early success in South Lokichar Rift Basin de-risks basinsDrilling2014+Drilling2013+Drilling2014+Drilling2015+Drilling2014+Drilling2012+Drilling2013+Drilling2014+Drilling2014+Slide 31

2013 HALF-YEARLY RESULTSIndustry-leading exploration acreage positionBalanced spread of E&A campaigns provide robust feedstock to sustain Tullow’saverage annual addition of 200MMboe mean resourcesSlide 32

2013 HALF-YEARLY RESULTSTullow Oil plc – 2013 Half-Yearly ResultsConclusions – Aidan Heavey

2013 HALF-YEARLY RESULTSRunning business for the long-term• Financial strength and funding of the business has never been stronger• Core oil producing assets continue to generate significant cash flow• Successfully replacing commercial reserves and contingent resources• Selectively developing / monetising key projects• Kenya and Ethiopia potential will significantly enhance value of the companyContinued track record of opening high-risk frontier basinsSlide 34

2013 HALF-YEARLY RESULTSTullow Oil plc – 2013 Half Yearly ResultsAppendix

mmboe2013 HALF-YEARLY RESULTSConverting Resources - portfolio management and developmentYear End Group Reserves and Resources2,0001,8001,6001,4001,2001,00080060040020002009 2010 2011 2012Uganda Commercialised Contingent Resources Commercial Reserves2012 YE Reserves and Resources 1,203 mmboe• Commercial Reserves - 388 mmboe- TEN transferred to Reserves - 112 mmbo• Contingent Resources - 815 mmboe- Uganda Resources commercialised - 604 mmboe- Additions to Resources - 71 mmboeTotal Resource potential 6.0 billion boe• Commercial Reserves - 6% of total• Reserve and Contingent Resource life ~37 years• Risked Prospective upside c.4.8bn boe - 60% increaseEurope and Asia6%1,203mmboeCommercialReserves29%6.0 bnboeCommercialReservesContingentResourcesContingentResources65%RiskedProspectiveUpsideSlide 36

2013 HALF-YEARLY RESULTSMozambique offers exciting opportunities with play diversity• Oil seeps to west & oil shows to north in recentIronclad-1• Rifted transform margin with broad play diversity– Large structural highs– Carbonate potential– Onlapping stratigraphic traps– 2 possible kitchens, one inboard, the other outboard• “Ibo High” 3D seismic: multiple follow-up prospects• Two wildcats and sidetrack planned for 2013– Cachalote-1 (with Haliote sidetrack): Q3 2013– Second well to followSlide 37

2013 HALF-YEARLY RESULTSMauritania core campaign drilling this yearSignificant play diversity in Mauritania acreage• 80 prospects with risk spread through multiple plays• Light oil & gas-condensate already proven in the basin• Testing new & deeper plays for bigger & better reservoirsFour independent exploration wells in 2013• Frégate:– Turonian turbidite channel over a structural nose which follows up onPetronia wet-gas kick at Cormoran-1• Tapendar:– structurally stacked Lower Miocene to Cretaceous targets in a saltmini-basin, like Mars Field (Gulf of Mexico)• Sidewinder:• Ibis:– material stratigraphic trap, Cretaceous lower-slope fan, like T.E.N.– stacked turbidite channels enhanced by structural trapping & chargedby possible southern oil kitchenSlide 38

2013 HALF-YEARLY RESULTSWest Africa Transform Margin campaign extended to GuineaGuinea• Acquired significant operated acreage position; 1.5 times existing WATM acreage• Play diversity offsets exploration risks; large structural-stratigraphic traps & carbonate leads• Sylli and Eos prospects competing for wildcat well drilling by early 2014Côte d’Ivoire• “TEN-type” exploration potential following Paon-1 success in CI-103• Paon-2 exploratory appraisal well to spud in CI-103 during 2014, Calao-1 was unsuccessfulSlide 39

2013 HALF-YEARLY RESULTSGuyanas: extensive “Jubilee play” potential plus upside plays• Jubilee play campaign continues across the Atlantic; Multiple Ghana-scaled prospective fan systems• New 3D seismic surveys reveal exciting drilling targets in Suriname and French GuianaSlide 40

2013 HALF-YEARLY RESULTSFocus on Suriname operated exploration for Jubilee play• Jubilee play campaign continues across the Atlantic, after Tullow’s successful Zaedyus-1 basin opener• Multiple Ghana-scaled prospective fan systems overlying Ivorian-style Albian fault block plays• New 3D seismic surveys reveal exciting material stacked drilling targets in our Suriname Block 47• Tullow 70% operated position, provides control over direction & execution of exploration strategySlide 41

2013 HALF-YEARLY RESULTSNorth Atlantic exploration shifts into exciting drilling phaseGreenland - highly prospective acreage• 1,800 sq km 3D seismic acquired• Evaluation of licence to continue to 2015• Acreage on prime location in Melville Bay Basin• Billion barrel prospect mapped, with follow up• Reviewing options to realise valueNorway - relatively unexplored vs UK• Spring Energy: experienced exploration team• Very attractive exploration fiscal regime• Highly prospective oil basins, excellent monetisation options• Wisting in Barents Sea; spud expected Aug 2013• Mantra, Kuro & Gotama adjacent to Troll; Mantra spuds 2013Slide 42

2013 HALF-YEARLY RESULTS63% global E&A success ratio year to dateSeismic KeyAcquisitionNORWAY - 2 wells†Processing/Re-processingMulti client surveyDrilling KeyOffshoreMAURITANIA1,720 sq km3D PSDM Carlsberg-1 Mjosa-12,600 sq km 3D PSTM600 km 2D PSDM1,000 sq km 3D PSDMCONGO (BRAZZAVILLE) - 4 wells Mboundi - 2101A Mboundi - 2005 ST Mboundi - 2102A Mboundi - 2001 STOnshoreFRENCH GUIANA - 2 wells Priodontes-1 Cebus-1GUINEA4,080 sq km3D PSDM5,751 sq km3D PSDMGABON - 2 wells OMBG-102 OMBG-201ETHIOPIA - 1 well Sabisa-1602 km 2D(Oil Shows -basin opener)550 km 2D PSTMKENYA - 2 wells74% success rate in 201274% success rate in 201183% success rate in 2010Wells Currently DrillingNorwayKenyaMozambiqueSURINAMEAugunshaug-1Ekales-1Buzio-13,864 sq km 3D PSDM200 km 2D PSDMURUGUAYCÔTE D’IVOIRE - 1 well Calao-11,566 sq km 3D †1,000 sq km 3D PSTM †GHANA - 3 wells Enyenra-6A Sapele-1 Ntomme-4WI889 sq km889 sq km 3D3D PSTMMOZAMBIQUE - 2 Wells Cachalote-110,368km 2D † Haliote-11,000 sq km2D PSDM †UGANDA - 8 wells Lyec-1 Ngiri-5 Ngiri-6 Ngiri-7 Paipai-1 Etuko-1 Ondyek-1 Mpyo-2 Mpyo-4 Gunya-259 sq km 3D855 km 2D800 km2D PSTMSlide 43

2013 HALF-YEARLY RESULTS12 month Exploration and Appraisal programme (Jul 2013)mmboeCountry Block Prospect/Well Interest Gross Mean Net Mean Spud DateWEST & NORTH AFRICACôte d’Ivoire CI-103 Paon-2A 30% (op) 1 287 86 Q4 2013This continuation of the early stage Côte d’Ivoire campaign is directly following up from the breakthrough success at Paon-1 in 2012.A further successful well would drill out and de-risk a cluster of prospects in Côte d’Ivoire, similar to those that led to the TEN field discoveries in Ghana.GabonDE-7 M.Oba 28.6% 10 2 Q3 2013Kiarsseny Perroquet 50.1% (op) 14 7 Q3 2013Nziembou Igongo 40% 9 3 Q1 2014Arouwe Sputnik East 29.75% 206 61 Q2 2014In addition to our planned exploration wells, Tullow’s exploratory appraisal drilling in Gabon has a very good track record of replacing reserves and sustaining production.We expect these exploration wells to add to the success of the 2012 appraisal programme.MauritaniaBlock 7 Frégate (Scorpion) 36.15% 293 106 Aug 2013C-10 Tapendar 59.15% (op) 103 61 Q4 2013C-6 Sidewinder 88% (op) 276 243 Q1 2014Block 1 Ibis 40% 156 62 Q2 2014Immediate focus is on the play-testing wells Frégate-1 and Tapendar-1. These wildcats will be followed by two more testing the Sidewinder and Ibis prospects.We plan to follow up on any success with the re-prioritisation of the 80 prospects in our inventory and the launching of extensive basin drill-out campaigns.Guinea Guinea Offshore Eos 40% (op) 288 115 Q1 20143D seismic acquired, processed & interpreted over deep water turbiditic Eos and Sylli prospects. Eos is scheduled for drilling Q1 2014, with very significant follow-up prospectivity recognisedto the east. Potential for further 3D seismic acquisition in 2014 across remaining leads and prospectsNote : 1 - Tullow is reducing its interest to 30% in this licence. The deal is subject to government approval.Slide 44

2013 HALF-YEARLY RESULTS12 month Exploration and Appraisal programme (Jul 2013)mmboeCountry Block Prospect/Well Interest Gross Mean Net Mean Spud DateSOUTH & EAST AFRICAEthiopiaKenyaTultule25 13 Aug 2013South OmoShimela 50% (op)88 44 Q4 2013Kesami 23 12 H1 2014Ekales53 27 July 201313TAgete (Twiga N) 68 34 Sept 201350% (op)Twiga South appraisal 40 20 H2 2013/2014Tausi 56 28 H1 201410 BA Kiboko 50% (op) 52 26 H2 2014Etuko-193 47 In progressAmosing 59 27 Oct 2013Ewoi-1 44 22 H2 201310BBEkosowan 40 20 H1 201450% (op)Linga-1 56 28 H1 2014Ngamia-West 33 17 H1 2014Etuko appraisal wells TBC TBC 2014Ngamia appraisal wells 70 35 2014With over 120 leads and prospects there is no shortage prospectivity and follow-up potential in this pioneering and vast exploration campaign. Near-term activities focus should not deterattention away from the tremendous scale of the volume potential in this new oil province which will be addressed through our continued systematic ramp-up of the campaign, as more drillingand geophysical surveying teams are deployed, building on our initial successes.Uganda EA-1 Area wide appraisal drilling 33.3% various various 2013/2014Our licences continue to deliver multiple and attractive oil appraisal opportunities in support of our preparations for basin development.Mozambique Block 2 Buzio 25% 129 32 In progressFollowing the Cachalote-1 result, the immediate attention falls and the second prospect Buzio - if this is successful then the follow-on potential is very considerable. The Ibo High may be actingas a broad focus area for regional hydrocarbon charge, hopefully trapping oil. If so then there are some 20 leads &prospects within the licence which sets up a very material opportunity toleverage from any early success.Slide 45

2013 HALF-YEARLY RESULTS12 month Exploration and Appraisal programme (Jul 2013)mmboeCountry Block Prospect/Well Interest Gross Mean Net Mean Spud DateEUROPE, SOUTH AMERICA & ASIAThe Netherlands E11 Vincent 60% (op) 32 19 Q3 2013NorwayPL 537 Wisting Central 20% 138 28 Q3 2013PL 537 Wisting Main 20% 220 44 Q3 2013PL 405 Butch East 15% 166 25 Q4 2013PL 405 Butch SW 15% 93 14 Q1 2014PL 542 Augunshaug 40% 24 10 In progressPL 551 Mantra 80% (op) 147 118 Q4 2013PL 659 Langlitinden (Matrosen) 10% 261 26 Q4 2013PL 550 Gotama 80% (op) 96 86 Q1 2014PL 507 Lupus 80% (op) 239 191 H1 2014Our exploration inventory and campaigns in Norway will continue to be built up through the years ahead, far beyond this current 12 month programme. Tullow’s exciting Barents Sea frontieracreage provides transformational new exploration opportunities for opening and extending new plays. Our Norwegian Sea and northern North Sea acreage has multiple proven and new playsand prospects close to existing infrastructure for quick monetisation.French Guiana Guyane Maritime Zaedyus Downdip 27.50% Refer to the Operator Q3 2013With over 20 material leads & prospects this is an important new oil province, proven by Tullow’s pioneering Zaedyus-1 well. There is a large inventory of E&A prospects targeting significant oilplays, which stand to be de-risked by 3D seismic data and Zaedyus Downdip in 2013.Slide 46

2013 HALF-YEARLY RESULTSDownload the Tullow Investor Relations andMedia App from the Apple and Android stores:Follow Tullow on:Tullow Oil plc9 Chiswick Park566 Chiswick High RoadLondon, W4 5XTUnited KingdomTel: +44 (0)20 3249 9000Fax: +44 (0)20 3249 8801Email: chris.perry@tullowoil.com